C ENTER RECE. Chevron

Transcription

1 ENTER FOR SUSTAINABLE SHA LE DEV ELOPMEE NT, IN. REE RTIFIATION AUDIT SUMMARY REPORT hevron - Appalachian Mountain Businesss Unit (AMBU) O c tober

2 ompany AUDIT INFORMATION OPERATOR INFORMATION hevron AMBU - Appalachian Mountain Business Unit Address 700 herrington Parkway, oraopolis, PA AUDITING FIRM INFORMATION Lead Auditor John Stangline Abbreviation JAS Auditor(s) Hans Umhoefer Abbreviation HU Water Performance Standards Audited: Air Performance Standards Audited: Field/Office Auditor Days Scope of ertification: Standard Standard Start Date of Audit End Date of Audit Start Date of Audit End Date of Audit Offsite Total Auditor 4 Auditor Days Days 14 These standards apply to unconventional exploration, development, and gathering activities including site construction, drilling, hydraulic fracturing and production in the Appalachian Basin. These regional standards consider geology, topography, population density, infrastructure, surface water, ground water and other issues of particular concern in the Appalachian Basin. Accordingly, until such time as the scope of these standards may be amended, these standards and the SSD evaluation and certification process will be limited to Operators unconventional activities in the Appalachian Basin. Audit Objectives The audit objective was to assure continued conformance of the Appalachia Basin assets of hevron s Appalachian Mountain Business Unit (AMBU) to the enter for Sustainable Shale Development (SSD) Environmental Performance Standards. This audit report identifies areas of conformance or non-conformance, observations, and applied best practices. 1 P age

3 SUMMARY hevron s Appalachian Mountain Business Unit (AMBU), formerly the Appalachian Michigan Business Unit, achieved certification to the enter for Sustainable Shale Development s (SSD) Performance Standards on September 18, 2014 and successfully completed an annual certification assurance review on September 19, Pursuant to certification requirements and on behalf of the SSD, Bureau Veritas ertification (BV) conducted a recertification audit of hevron AMBU operations within the Appalachian Basin. The recertification audit was conducted for conformance to the SSD Performance Standards (Version 1.4) and in accordance with the requirements of the SSD Verification Protocol (Version 1.1) and Guidance for Auditors (Version 1.4). A scoping meeting was held remotely on July 14, 2016 to review the geographical and operational scope of hevron AMBU activities in the Appalachian Basin and to determine the appropriate set of recertification audit sites for field verification. The desktop portion (document review) of this audit was performed at hevron AMBU offices in oraopolis, Pennsylvania on August 8 and 12, The field verification portion of the audit was performed at locations in Pennsylvania and West Virginia on August 9, 10 and 11, Each site was visited by a team of at least two auditors with guides from hevron AMBU. The verification process included audit team observations, interviews with responsible management, planning and operations personnel, documentation review and site tours. Where necessary and appropriate, the auditors requested explanations of site observations, equipment performance, operations, operating procedures and reviewed documents and records to demonstrate the level of conformance to the standards. Over the course of the audit, the auditors reviewed approximately 95 records and documents and interviewed 13 employees (2 office based, 11 field personnel) to determine conformance with the performance standards. Table 1, titled SSD Recertification hevron AMBU Audit Summary Scorecard summarizes BV s audit findings with respect to each performance standard. Table 2, titled SSD Recertification Field Verification Visits, hevron AMBU outlines the locations and associated operations visited for observation and verification of conformance to the SSD Performance Standards. The sites selected include a cross section of hevron AMBU s operations and geographic locations within the Appalachian Basin that were active during the audit operational window as required by SSD s Verification Protocol. The standards identified in Table 2 for each site are a sample of the areas of field observation and verification addressed by the audit team. 2 P age

4 Table 1: SSD Recertification hevron AMBU Audit Summary Scorecard WATER WATER PERFORMANE STANDARDS Finding (,N,NA)* 1.0 Std 1: No wastewater discharge 1.1 Maintain zero discharge of wastewater (including drilling, flowback and produced waters) to Waters of the ommonwealth of PA and other states. 1.2 In order to facilitate comprehensive wastewater management programs that consider environmental, safety, health, and economic factors, Operators may send shale wastewater to a entralized Waste Treatment facility (WT) for treatment and discharge if the Operator demonstrates certain conditions are satisfied at the WT. 1.3 Prior to using a WT that may discharge, the operator must conduct an evaluation of the WT s performance and permit compliance status. NA 1 NA Operator must conduct WT effluent monitoring. NA Operators may not initiate, and will immediately cease, deliveries to a WT if the SSD determines the WT discharges increase the risk of harm to human health or the environment or is in susbstantial non-compliance with its NPDES permit. 1.6 Operator shall provide WT evaluation data to the SSD and in the event of identifying potential non-compliance findings, shall notify the WT, the permitting agency, and SSD. 2.0 Std 2: Recycle water NA 1 NA Maintain a plan to recycle flowback and produced water, for usage in drilling or fracturing a well, to the maximum extent possible. 2.2 Recycle a minimum of 90% of the flowback and produced water, by volume, from wells in all core operating areas in which an Operator is a net water user. 2.3 SSD will consider a recycling standard for a net water producer within one year. Operators will maximize the use of recycled water to the extent possible during this time. 3.0 Std 3: losed loop drilling / pits 3.1 Any new pits designed shall be double-lined and equipped with leak detection. 3.2 ontain drilling fluid, when using oil-containing drilling fluids to drill a well, in a closed loop system at the well pad (e.g. no ground pits). 3.3 ontain all drilling fluid and flowback water in a closed loop system at the well pad, eliminating the use of pits for all wells. NA 2 * = onformance with the standard NA = Not applicable 1 hevron AMBU did not utilize a WT. Therefore, Standards 1.2 through 1.6 are not applicable for hevron AMBU. 2 No new pits are in use or planned by hevron AMBU, therefore, Standard 3.1 does not apply for hevron AMBU. 3 P age

5 4.0 Std 4: entralized wastewater impoundments 4.1 Ensure that free hydrocarbons are removed from the water prior to storage; new impoundments must be double-lined with an impermeable material, equipped with leak detection; and take measures to reasonably prevent hazards to wildlife. 5.0 Std 5: Geologic risk assessment 5.1 Establish an Area of Review, prior to drilling a well, which encompasses both the vertical and horizontal legs of the planned well; conduct a comprehensive characterization of subsurface geology, including a risk analysis; and conduct a thorough investigation of any active or abandoned wellbores within such area of review or other geologic vulnerabilities (e.g., faults) that penetrate the confining layer and adequately address identified risks. 6.0 Std 6: Groundwater monitoring 6.1 Develop and implement a plan for monitoring existing water sources and demonstrate that water quality and chemistry measured during a pre-drilling assessment are not impacted by operations. 6.2 onduct periodic monitoring for at least one year following completion of the well and monitoring must be extended if results indicate potentially adverse impacts on water quality or chemistry by operations. 6.3 Develop and implement an investigative and corrective action plan if monitoring establishes a possible link between an Operator s activities and of contamination of a water source NA onduct additional monitoring in the event a well is re-stimulated. 7.0 Std 7: Well integrity; fluid design & disclosure 7.1 Design and install casing and cement to completely isolate the well and all drilling and produced fluids from surface waters and aquifers and prevent vertical movement of fluids in the annulus. 7.2 Do not use diesel fuel in the hydraulic fracturing fluids. 7.3 Publically disclose the chemical constituents intentionally used in well stimulation fluids. 7.4 Work toward use of more environmentally neutral additives for hydraulic fracturing fluid. 7.5 Perform mechanical integrity tests when refracturing an existing well. NA 4 3 hevron AMBU does not utilize centralized impoundments to store flowback water or produced water in the Appalachian Basin; therefore, Standard 4.1 does not apply to hevron AMBU. 4 hevrons AMBU has not performed re-fracturing operations in the Appalachian Basin during the certification period nor are refracturing operations planned at the time of the audit; therefore, Standard 7.5 does not apply to hevron AMBU. 4 P age

6 8.0 Std 8: Spill containment & emergency response 8.1 Design each well pad to minimize the risk that drilling related fluids and wastes come in contact with surface waters and fresh groundwater. 8.2 Develop and implement an emergency response plan and ensure local responders have appropriate training and equipment to respond to an emergency at the well. 8.3 In the event of spill or release, beyond the well pad, immediately provide notification to the local governing body and any affected landowner. 5 P age

7 AIR AIR PERFORMANE STANDARDS 9.0 Std 9: gas to pipeline/ limited flaring 9.1 Direct all pipeline-quality gas during well completion of development wells, and re-completion or workover of any well into a pipeline for sales. 9.2 Any gas not captured and put in the sales pipeline may not be vented and must be flared (in accordance with Standard No. 10). 9.3 Acceptable reasons for sending gas to a flare and not directing gas into the sales line include: (a) Low content of flammable gas and (b) for safety reasons. 9.4 ircumstances unacceptable for sending gas to flare, instead of directing it into a sales line, are: (a) lack of a pipeline connection except for wells that are designated as either exploratory or extension wells; (b) inadequate water disposal capacity; and (c) undersized flow back equipment, lack of flow back equipment or lack of equipment operating personnel. 9.5 Document any upset or unexpected condition that leads to flaring of gas and maintain records of description of the condition, the location, date, and quantity of gas flared. 9.6 Exploratory well verification 10.0 Std 10: Flare operation, if permitted 10.1a Use raised/elevated flares or an engineered combustion device with a reliable continuous ignition source, which have at least a 98% destruction efficiency of methane. Pit flaring is not permitted. 10.1b Flaring may not be used for more than 14-days on any development well and no more than 30-days on any exploratory or extension wells. If flaring continues beyond 30-days for an exploratory or extension well, document the extent of additional flaring and reasons requiring flaring beyond the 30-days. 10.1c Flares shall be designed for and operated with no visible emissions, except for periods not to exceed a total of five minutes during any two consecutive hours Std 11: Engine emissions - rig; frac pumps 11.1a-e Dedicated horizontal drill rig (non-road) diesel - average emissions must be equivalent to Tier 2 non-road diesel engine standards or better. All horizontal drill rig diesel non-road equipment must use Ultra-Low Sulfur Diesel fuel (15 ppm of sulfur) at all times. 11.2a-b Dedicated frac pump diesel engines - average emissions must be equivalent to Tier 2 non-road diesel engine standards or better. All frac pump diesel engines must use Ultra-Low Sulfur Diesel fuel (15 ppm of sulfur) at all times. 6 P age

8 12.0 Std 12: Engine emissions - compressors 12.1 Existing compressor engines greater than 100 horsepower may not emit more than 1.5 grams of NOx per horsepower-hour Any new, purchased, replacement, reconstructed, or relocated lean-burn engines greater than 100 horsepower may not emit more than 1.0 g/hp-hr for NOx; 2.0 g/hp-hr for O; 0.7 g/hp-hr for VOs Any new, purchased, replacement, reconstructed, or relocated lean-burn engines greater than 500 horsepower may not emit more than 0.5 g/hp-hr for NOx; 47 15% O2 or 93% reduction of O; 0.2 g/hp-hr for VOs; and 0.05 g/hp-hr for HHO Any new, purchased, replacement, reconstructed, or relocated rich-burn engines greater than 100 horsepower and up to 500 horsepower may not emit more than 0.25 g/hp-hr for NOx; 0.3 g/hp-hr for O; 0.2 g/hp-hr for VOs Any new, purchased, replacement, reconstructed, or relocated rich-burn engines greater than 500 horsepower may not emit more than 0.2 g/hp-hr for NOx; 0.3 g/hp-hr O; 0.20 g/hp-hr for VOs; 2.7 ppmvd at 15% O2 or 76% reduction for HHO Std 13: Tank VO emissions 13.1 All individual storage vessels at the well pad with VO emissions equal to or greater than 6 tpy must install controls to achieve at least a 95% reduction in VO emissions Std 14: Fugitive emissions - controllers, seals, inspection 14.1 hange rod packing at all reciprocating compressors (both existing and new), including those at the wellhead, either every 26,000 hours of operation or after 36 months All pneumatic controllers must be low bleed, with a natural gas bleed rate limit of 6.0 scfh or less or zero bleed when electricity (3-phase electrical power) is on-site Replace worn out wet seals on existing centrifugal compressors with dry seals Implement a directed inspection and maintenance program (DIM) for equipment leaks from all existing and new valves, pump seals, flanges, compressor seals, pressure relief valves, open-ended lines, tanks and other process and operation components that result in fugitive emissions. Monitor weekly (OVA) and annually (FLIR). Once significant leaks are detected, they are required to be repaired in a timely manner Eliminate VO emissions associated with the prevention of well-bore freezeup Pressurize compressors when they are off-line for operational reasons to reduce blowdown emissions. NA 5 NA 5 NA 5 NA 6 5 The hevron AMBU compressor engines were pre-existing at the time of certification and none of the compressor engines are new, purchased, replacements, reconstructed, or relocated. 6 hevron AMBU does not operate centrifugal compressors in the Appalachian Basin; therefore Standard 14.3 does not apply. 7 P age

9 15.0 Std 15: Engine emissions - water fleet, other % of all trucks used to transport fresh water or well flowback water must meet U.S. EPA s Final Emission Standards for 2007 and Later Model Year Highway Heavy-Duty Vehicles and Engines for particulate matter (PM) emissions By September 24, 2015, 95% all trucks used to transport fresh water or well flowback water must meet U.S. EPA s Final Emission Standards for 2007 and Later Model Year Highway Heavy-Duty Vehicles and Engines for particulate matter emissions All on-road vehicles and equipment must limit unnecessary idling to 5 minutes, or abide by applicable local or state laws if they are more stringent All on-road and non-road vehicles and equipment must use Ultra-Low Sulfur Diesel fuel (15 ppm of sulfur) at all times. 8 P age

10 Table 2: SSD Recertification - Field Verification Visits hevron AMBU Site Name Assessors Date General Location Operation / Activity Key SSD Performance Standards Assessed Ritter_A JAS, HDU August 9, 2016 Southwest Pennsylvania Production dry gas 1 - Zero discharge, 8 ontainment and ERP, 14 ontrollers, hemical Injectors, LDAR (Leak Detection San Filippo_A Production dry gas 1 - Zero discharge, 8 ontainment and ERP, 14 ontrollers, hemical Injectors, LDAR (Leak Detection Sargent_A Production dry gas 1 - Zero discharge, 8 ontainment and ERP, 14 ontrollers, hemical Injectors, LDAR (Leak Detection Wicks ompressor Station 1 operating compressor engine onner_a JAS, HDU August 10, 2016 Northwest West Virginia Production wet gas 1 - Zero discharge, 8 ontainment and ERP, 12 - Engine Emissions, 14 Rod Packing, ontrollers, Blowdown for Operations LDAR (Leak Detection and Repair) 15 - Truck idling 1 - Zero discharge, 8 ontainment and ERP, 13 Tanks / VO, 14 ontrollers, hemical Injectors, LDAR (Leak Detection Hart_B Production wet gas 1 - Zero discharge, 8 ontainment and ERP, 13 Tanks / VO, 14 ontrollers, hemical Injectors, LDAR (Leak Detection Berger_A Production wet gas 1 - Zero discharge, 8 ontainment and ERP, 13 Tanks / VO, 14 ontrollers, hemical Injectors, LDAR (Leak Detection aveny_a Production wet gas 1 - Zero discharge, 8 ontainment and ERP, 13 Tanks / VO, 14 ontrollers, hemical Injectors, LDAR (Leak Detection urry_a August 10, 2016 Northwest West Virginia Production wet gas 1 - Zero discharge, 8 ontainment and ERP, 13 Tanks / VO, 14 ontrollers, hemical Injectors, LDAR (Leak Detection 9 P age

11 Site Name Assessors Date General Location Operation / Activity Key SSD Performance Standards Assessed Miller_A JAS, HDU August 11, 2016 Southwest Pennsylvania Production dry gas 1 - Zero discharge, 8 ontainment and ERP, 14 ontrollers, hemical Injectors, LDAR (Leak Detection PBG Smith_A Production dry gas 1 - Zero discharge, 8 ontainment and ERP, 14 ontrollers, hemical Injectors, LDAR (Leak Detection Bedilion_A Production dry gas 1 - Zero discharge, 8 ontainment and ERP, 14 ontrollers, hemical Injectors, LDAR (Leak Detection Grooms_A Production dry gas 1 - Zero discharge, 8 ontainment and ERP, 14 ontrollers, hemical Injectors, LDAR (Leak Detection * VO Volatile Organic ompound ** ERP Emergency Response Plan 10 P age